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© 2009 Baker Hughes Incorporated. All Rights Reserved.
The Use of DRA in Crude OilCOQA MeetingJune 10, 2010
David SchwartzBaker Hughes
Preview
• Background• Crude quality and DRA
–Key challenges –DRA chemistry and product composition–DRA fate testing
• Summary and Conclusions
(DRA is a “Drag Reducing Agent”)
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Benefits of Drag Reducers
• Increased throughput– Without capital expenditure (new pumps, lines, etc.)– Allows pipelines to meet their scheduled nominations
• Energy savings– Cheaper than horsepower…can shut down pump stations
• Scheduling flexibility– Increases slow (or fast) component of line batches
• Derated periods– Maintain desired throughput at reduced MAOP– Maintain throughput during scheduled maintenance
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Effect of DRA• DRA dissolves in the pipeline liquid• DRA decreases turbulent flow and increases laminar flow• DRA does not coat the pipeline wall
Without Without DRADRA
TurbulentTurbulentCoreCore
With With DRADRA
BufferBufferZoneZone
LaminarLaminarSublayerSublayer
Chemistry of Drag Reducers• DRA active ingredient
– Ultra-high molecular weight, linear poly-alpha-olefin– 100% hydrocarbon, ultra high MW, completely saturated
• DRA product types– Gel
• Older technology, polymer “dissolved” in a hydrocarbon solvent
– Slurry• Typically water-based• Freeze-protected versions also contain alcohol and/or glycol ether• Typically much higher performance than the gel products, and easier
to handle
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xR R R
DRA Product Composition
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Product type Polymer (%) Carrier(s) (%) Other Ingredients
Gel Polyolefin (10%)
Kerosene, pentane (90%)
None
Water-based slurry
Polyolefin (20-30%)
Water (60-75%)
Stabilizing agents (up to 5%)
Freeze-protected slurry
Polyolefin (20-30%)
Alcohol, glycol, glycol ether (10-75%)
Stabilizing agents (up to 5%)
Typical percentage composition ranges shown
Crude Oil Quality and DRA—Key Challenges
•Refinery process differences– Straight run cuts vs hydrotreated; product slate; etc.
•Complexity of the DRA additive– Some DRA’s have 5 or more components– How low do you go? 1% of DRA, 0.1%, lower??
•Refiners’ perception of DRA risk vs reward•Our direct customers are pipeline companies•Any process impact could be small/slow
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Crude Oil Quality and DRA--History• DRA additives first used in crude oil in 1979, on the trans-
Alaskan pipeline system
• Around that time, we did the following work :– Impact testing at two refineries
• Process condition changes, product specs, trace metals levels
– Lab testing examining desalter impact, foaming tendency and acidnumber
• Since that time, DRA has been used to treat over 100 billion barrels of crude, all around the world
• No major problems tied to DRA
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Who Uses DRA in Crude Oil
Shell ExxonMobilPEMEX EnbridgeAlyeskaMarathon
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BPMaersk Saudi AramcoIOCL YPFSinclairSunoco
PERN SUMEDCEPEKOCKTOCPCBTC
DRA Fate Testing• Desalter
– Octanol/water partition coefficient (Log Pow)– EDDA– COD/BOD
• Refined product quality– TGA– Pyrolysis GC-MS– Spec testing on cut (spiked with DRA component(s) or distilled
from DRA-containing crude)
• Process impact– All of the above– Elemental analysis– Chemical and process knowledge
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Testing for the Presence of DRA
• It’s relatively easy to test a refined fuel sample for DRA
– Polymer—GPC, NMR, filterability– Carriers—GC/MS– Stabilizing agents—IR, GC/MS, etc.
• Not so easy for a crude sample, due to the crude’s complex composition
© 2009 Baker Hughes Incorporated. All Rights Reserved.
DRA Polymer Fate
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Polymer degrades at 400 C
TGA
DRA Polymer Fate Testing
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Polymer degrades to its monomers (alpha-olefins), at 400 C
Peaks C and G are monomers
GC-MS
DRA Component Fate in a Refinery
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Component Level in crude
Expected fate
Polymer 20 ppm VDU bottoms, then similar to other non-volatile, saturated hydrocarbons
Alcohol 30 ppm Distills in ADU, based on boiling point
Stabilizing agent(s) 5 ppm Varies
Assume a crude contains100 ppm of a freeze-protected DRA additive (20% polymer, 45% water, 30% alcohol, 5% stabilizing agents):
Typically, the polymer and carrier(s) will not be water soluble
Summary and Conclusions• DRA has been used in crude oil for over 30 years, over 100 billion barrels have been treated
• DRA additives provide significant benefits to crude producers, transporters, refiners and end users
• There are several real challenges in the area of DRA and crude quality
• We want to work with you to address any concerns you might have with respect to DRA
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Thank you
Questions?
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Supporting Information Follows
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Slurry DRA Stabilizing Agents
• A slurry stabilizing agent package must be “tri-functional”– Partitioning (prevent agglomeration)– Wetting (prevent liquid/solid separation)– Rheology (slow down rate of separation)
• Typical slurry stabilizing agents– Metal stearates, sulfates, phosphates– Polyolefin waxes– Organic stearamides– Clays– Fatty acid waxes– Silica
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EDDA Testing with FLO MXA
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Sample Dose Rate (ppm)BPR27140
Water Drop WQ Interface
5’ 10’15’
20’ 25’ 30’ GN/A
Light crude(no DRA additive)
0 0.5 0.60.6
0.6 0.6 0.6G
N/A
10 0.2 0.40.5
0.6 0.8 0.8G
N/A
30 0.6 0.9 1.5 2 2.2 3 G- GLC w/ additive 0 9 9 9 9 9 9 G G
10 9 9 9 9 9 9 G- G30 9 9 9 9 9 9 G- G
Heavy crude no additive 0 1.5 2.2 2.8 3 4 4 G G-
10 3.5 5 6 6 7 8 G G-
30 4.5 5.5 6.5 7 8 8 G G-
HC w/additive 0 3 3.5 3.5 4 5 5 G G-
10 3.5 5 5. 6 6 7 G G-
30 4 5.5 5.5 6 7 7 G G-
Sample 0 % Water %
BS
% Total % Slug
LC –no additive 0 1.2 1.2 0.6 (plug) no water
LC w/ additive Tr 0.4 0.4 0.4
HC no additive 0.1 0.6 0.6 0.2/0.4 (0.2% plug)
HC w/additive 0 0.4 0.4 0.2
Initial BS&W
© 2009 Baker Hughes Incorporated. All Rights Reserved.
© 2009 Baker Hughes Incorporated. All Rights Reserved.
DRA and Refined Fuel Product Quality
•EPA registration as a fuel additive•Sulfur and metals levels•Impact on fuel’s spec. properties
– Corrosivity, filter plugging, cloud point, gums, etc.•Engine testing•Behavior in biofuels
– Diesel/biodiesel blends– Ethanol/gasoline blends
© 2009 Baker Hughes Incorporated. All Rights Reserved.